Logging and correlation prediction plot in real-time

ABSTRACT

In one embodiment, a method includes facilitating a real-time display of drilling-performance data for a current well. The method further includes receiving new channel data for the current well from a wellsite computer system. The method also retrieving input data including historical drilling-performance data for an offset well relative to the current well. In addition, the method includes computing calculated data for the current well based on the channel data and the input data. Moreover, the method includes updating the real-time display with the calculated data.

CROSS-REFERENCE TO RELATED APPLICATIONS

This patent application is a continuation of U.S. patent applicationSer. No. 15/343,836, filed Nov. 4, 2016, now U.S. Pat. No. 10,209,400.U.S. patent application Ser. No. 15/343,836 is a continuation of U.S.patent application Ser. No. 13/919,240, filed on Jun. 17, 2013, now U.S.Pat. No. 9,518,459. U.S. Patent Application Ser. No. 13/919,240 claimspriority from U.S. Provisional Patent Application No. 61/660,565, filedon Jun. 15, 2012. U.S. patent application Ser. Nos. 13/919,240 and15/343,836 and U.S. Provisional Patent Application No. 61/660,565 areincorporated by reference in their entirety.

BACKGROUND Technical Field

The present invention relates generally to drilling analytics and moreparticularly, but not by way of limitation, to systems and methods forenabling real-time drilling-performance analysis.

History of Related Art

As will be appreciated by one of ordinary skill in the art, well controlis a practice used in oil and gas operations such as drilling tomaintain the fluid column hydrostatic pressure to prevent, inter alia,influx of formation fluids into a wellbore and unintentional fracture ofa rock structure of a formation. The term formation encompasses soil,rock, and the like that are encountered when drilling. Well controloften involves the estimation of pressures, the strength of thesubsurface formations, and the use of casing and mud density to offsetthose pressures in a predictable fashion.

Two indicators that are frequently used in well control are porepressure and fracture gradient. Pore pressure refers to the pressure ofgroundwater held within a soil or rock in gaps between particles (i.e.,pores). A fracture gradient refers to an amount of pressure necessary topermanently deform, or fracture, a rock structure of a formation.Various methods are known for predicting pore pressure and fracturegradient. For example, one such method is known as the Eaton method. Byway of further example, another such method is known as the Matthews andKelly method.

While methods exist for predicting pore pressure and fracture gradient,it is not generally feasible to perform and have access to thesepredictions in real time as wells are being drilled. In addition, it isalso not generally possible to predict events in real time such as, forexample, lost circulation or a stuck pipe.

SUMMARY OF THE INVENTION

In one embodiment, a method includes, on a central computing systemcomprising at least one server computer, facilitating a real-timedisplay of drilling-performance data for a current well. The methodfurther includes the central computing system receiving new channel datafor the current well from a wellsite computer system. In addition, themethod includes the central computing system retrieving input datacomprising historical drilling-performance data for an offset wellrelative to the current well. The method also includes the centralcomputing system computing calculated data for the current well based onthe channel data and the input data. Additionally, the method includesthe central computing system updating the real-time display with thecalculated data.

In one embodiment, a system includes at least one server computer. Theat least one server computer is operable to perform a method. The methodincludes facilitating a real-time display of drilling-performance datafor a current well. The method further includes receiving new channeldata for the current well from a wellsite computer system. The methodalso retrieving input data comprising historical drilling-performancedata for an offset well relative to the current well. In addition, themethod includes computing calculated data for the current well based onthe channel data and the input data. Moreover, the method includesupdating the real-time display with the calculated data.

In one embodiment, a computer-program product includes a computer-usablemedium having computer-readable program code embodied therein. Thecomputer-readable program code is adapted to be executed to implement amethod. The method includes facilitating a real-time display ofdrilling-performance data for a current well. The method furtherincludes receiving new channel data for the current well from a wellsitecomputer system. The method also retrieving input data comprisinghistorical drilling-performance data for an offset well relative to thecurrent well. In addition, the method includes computing calculated datafor the current well based on the channel data and the input data.Moreover, the method includes updating the real-time display with thecalculated data.

BRIEF DESCRIPTION OF THE DRAWINGS

A more complete understanding of the method and apparatus of the presentinvention may be obtained by reference to the following DetailedDescription when taken in conjunction with the accompanying Drawingswherein:

FIG. 1 illustrates a system for facilitating real-timedrilling-performance analysis;

FIG. 2 illustrates a process for performing real-time drilling analysis;and

FIG. 3 illustrates an example of real-time drilling-performance analysisvia a real-time display.

DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS OF THE INVENTION

In various embodiments, real-time drilling-performance analytics suchas, for example, pore pressure and fracture gradient, can be facilitatedby leveraging historical drilling-performance data from offset wells. Asone of ordinary skill in the art will appreciate, an offset well is apre-existing well that is in close proximity to the current well. Forexample, an offset well can be located adjacently to the current wellaccording to spacing rules defined by applicable law. However, it shouldbe appreciated that immediate adjacency need not be required.

FIG. 1 illustrates a system 100 for facilitating real-timedrilling-performance analysis. The system 100 includes a wellsitecomputer system 102, a central computing system 108, and acommunications network 106. The wellsite computer system 102 includes acollection server 120, a remote-integration server 122, and a networklink 124. The central computing system 108 includes a main server 110, arepository server 112, and a network link 126. It should be appreciatedthat the depicted configurations of the central computing system 108 andthe wellsite computer system 102 are illustrative in nature. The centralcomputing system 108 and the wellsite computer system can each includeany number of physical or virtual server computers and databases. Forexample, in various embodiments, the remote-integration server 122 maybe omitted or have its functionality integrated into the collectionserver 120. Other modifications and rearrangements will be apparent toone of ordinary skill in the art after reviewing inventive principlescontained herein.

In a typical embodiment, the wellsite computer system 102 is located ator near a wellsite for a current well and communicates with the centralcomputing system 108 over the communications network 106. Thecommunications network 106 may include, for example, satellitecommunication between the network link 124 of the wellsite computersystem 102 and the network link 126 of the central computing system 108.Thus, the network link 124 and the network link 126 can be, for example,satellite links. For simplicity of description, communication betweenthe wellsite computer system 102 and the central computing system 108may be described below without specific reference to the network link124, the network link 126, and the communications network 106.

Using, for example, logging while drilling (LWD), the collection server120 receives and/or generates channel data 104 (e.g., in WITS0) via datareceived from sensors that are in use at the wellsite. A given sensor orother source of data is referred to herein as a “channel.” Data from achannel may be referred to as “channel data,” which term is inclusive ofboth raw data and metadata. The raw data includes, for example, measureddata determined by the sensor or source. The measured data can include,for example, resistivity, porosity, permeability, density, and gamma-raydata. The metadata includes information about the raw data such as, forexample, time, depth, identification information for the channel, andthe like. The collection server 120 transmits the channel data 104 tothe remote-integration server 122, which communicates the channel data104 to the central computing system 108 in real-time.

On the central computing system 108, the main server 110 receives thechannel data 104 from the wellsite computer system 102 and converts thechannel data 104 to a common data format. The conversion of channel datato a common data format is described in detail in U.S. patentapplication Ser. No. 13/829,590, which application is herebyincorporated by reference. As shown, the main server 110 has acalculation engine 128 resident thereon. Via the calculation engine 128,the main server 110 generates calculated data in real-time based on thechannel data 104. The calculation engine 128 can be, for example, asoftware application that implements algorithms to generate thecalculated data. Based on gamma-ray and resistivity data and other inputdata described with respect to FIG. 3, the calculated data can include,for example, pore pressure and a fracture gradient.

The calculation engine 128 can also maintain settings that are utilizedfor generating the calculated data. For example, implementation of Eatonand/or Mathews-and-Kelly algorithms may require certain parameters suchas an Eaton exponent, a matrix stress coefficient, and a Poisson ratio.In a typical embodiment, the settings maintained on the main server 110specify values for such parameters. If the value to be used for a givenparameter is not constant all across all wells (e.g. varying based ongeography or well-specific data), the settings further specify rules forselecting or calculating the value, as applicable. The settings permitthe calculation engine 128 to acquire necessary parameters without theneed for individual configuration for each well.

The repository server 112 stores and maintains the channel data 104 andany calculated data according to the common data format. Storage andmaintenance of data according to the common data format is described indetail in U.S. patent application Ser. No. 13/829,590, which applicationis incorporated by reference above. In a typical embodiment, therepository server 112 stores channel data from a plurality of wellsitecomputer systems located at a plurality of wellsites in this fashion. Inaddition, the repository server 112 typically maintains historicaldrilling-performance data (e.g., channel data, calculated data, etc.)for offset wells relative to the current well.

The repository server 112 facilitates a real-time display 114 ofdrilling-performance data related to the wellsite. In a typicalembodiment, the real-time display 114 is provided via a network such as,for example, the Internet, via a web interface. In a typical embodiment,the real-time display 114 includes gamma-ray and resistivity data for aformation being drilled. The real-time display 114 is shown and updatedin real time on a computing device 116 as the channel data 104 isreceived. In a typical embodiment, as described with respect to FIGS. 2and 3, the real-time display 114 allows engineering personnel 118 toperform real-time drilling analysis for the wellsite.

For purposes of illustration, examples of equations that can be used tocompute calculated data will now be described. In some embodiments, porepressure (Pp) can be computed using the Eaton method as embodied inEquation 1 below, where S represents stress (i.e. pressure exerted bythe weight of the rocks and contained fluids thereabove in units of,e.g., g/cc), PPN represents normal pore pressure according to ahydrostatic gradient, Ro represents observed resistivity, Rn representsnormal resistivity, and x represents an Eaton exponent.

$\begin{matrix}{{Pp} = {S - {\left( {S - {PPN}} \right)\left( \frac{Ro}{Rn} \right)^{x}}}} & {{Equation}\mspace{14mu} 1}\end{matrix}$

For purposes of this example, S, PPN, Ro, and Rn are input data forcalculating pore pressure. In particular, S and Ro are examples ofparameters that can be provided by channel data for the current well.The Eaton exponent (x) is an example of a parameter that can beretrieved from settings maintained by the calculation engine 128 ofFIG. 1. In some embodiments, PPN can also be retrieved from settingsmaintained by the calculation engine 128. In a typical embodiment, Rn isobtained using historical drilling-performance data for an offset well.In this fashion, pore pressure for the current well can be calculated inreal-time by retrieving resistivity data for the offset well. A specificexample will be described with respect to FIG. 3.

In various embodiments, a fracture gradient (Fg) can be computed usingthe Eaton method as embodied in Equation 2 below, where Pp and Srepresent pore pressure and stress, respectively, as described above andv represents a Poisson ratio.

$\begin{matrix}{{Fg} = {{Pp} + {\left( {S - {Pp}} \right)\left( \frac{v}{1 - v} \right)}}} & {{Equation}\mspace{14mu} 2}\end{matrix}$

For purposes of the example of Equation 2, stress (S), pore pressure(Pp) and the Poisson ratio (v) are input data for calculating a fracturegradient for a current well. Pp can be computed as described withrespect to Equation 1 above. Stress (S) can also be obtained asdescribed with respect to Equation 1. The Poisson ratio (v) is anexample of an input value that can be retrieved from settings maintainedby the calculation engine 128 as described with respect to FIG. 1.

In various embodiments, a fracture gradient (Fg) can also be computedusing the Matthews and Kelly method as embodied in Equation 3 below,where Pp and S represent pore pressure and stress, respectively, asdescribed above and κ_(i) represents a matrix stress coefficient.Fg=Pp+(S−Pp)κ_(i)  Equation 3

For purposes of the example of Equation 3, stress(S), pore pressure (P)and the matrix stress coefficient (κ_(i)) are input data for calculatinga fracture gradient for a current well. The pore pressure (Pp) andstress (S) can be obtained as described with respect to Equation 2.κ_(i) is an example of an input value that can be retrieved fromsettings maintained by the calculation engine 128 as described withrespect to FIG. 1.

FIG. 2 illustrates a process 200 for performing real-time drillinganalysis using the system 100 of FIG. 1. At step 202, the wellsitecomputer system 102 collects the channel data 104 in real-time fromsensors via, for example, LWD. The channel data 104 is received in aninitial data format such as, for example, WITS0. From step 202, theprocess 200 proceeds to step 204. At step 204, the wellsite computersystem 102 transmits the channel data 104 to the central computingsystem 108 via the communications network 106. From step 204, theprocess 200 proceeds to step 206. At step 206, the central computingsystem 108 receives the channel data from the wellsite computer system102. From step 206, the process 200 proceeds to step 208.

At step 208, the central computing system 108 converts the channel data104 to a common data format. From step 208, the process 200 proceeds tostep 210. At step 210, the channel data 104 is stored on the centralcomputing system 108 according to the common data format. From step 210,the process 200 proceeds to step 212. At step 212, the calculationengine 128 generates calculated data based on the channel data 104,settings, and other input data described with respect to FIG. 3. Asdescribed above, the calculation engine 128 may be, for example, asoftware application that implements algorithms to generate thecalculated data. From step 212, the process 200 proceeds to step 214. Atstep 214, the central computing system 108 stores the calculated data.For example, the calculated data can be stored on the repository server112. From step 214, the process 200 proceeds to step 216. At step 216,the central computing system 108 updates the real-time display 114 toinclude selected data such as, for example, all or part of the channeldata 104 and all or part of the calculated data. An example of thereal-time display 114 will be described in greater detail with respectto FIG. 3. From step 216, the process 200 proceeds to step 218. At step218, the process 200 ends.

FIG. 3 illustrates an example of real-time drilling-performance analysisvia a real-time display 314. To facilitate comparative analysis, forexample, by a drilling engineer, the real-time display 314 depictsdrilling-performance data for both a current well 340 and an offset well342 relative to true vertical depth (TVD). In a typical embodiment, theoffset well 342 is pre-selected and associated with the current well 340due to its geographic proximity to the current well 340. In variousembodiments, the pre-selection can be made by drilling personnel such asa drilling engineer and stored by a repository server such as therepository server 112 of FIG. 1.

The drilling-performance data depicted by the real-time display 314 caninclude, inter alia, selected channel data, input data, calculated data,casing-point data, and event data. The selected channel data includes,for example, channel data from a well site that is received at a centralcomputing system, converted to a common data format, and stored asdescribed with respect to FIGS. 1 and 2. The input data is additionaldata that is received, for example, from a drilling engineer or fromother data stored within a repository such as a repository maintained bythe repository server 112 of FIG. 1. The calculated data is data that iscalculated, for example, by a calculation engine such as the calculationengine 128 of FIG. 1. The casing-point data includes information relatedto the placement and size of casing utilized in a given well. The eventdata is data related to certain detected events at a well such as, forexample, a stuck pipe, lost circulation, or a kick (i.e., undesiredinflux of formation fluid into the wellbore).

With respect to the current well 340, the real-time display 314 showsselected channel data, input data, calculated data, and casing-pointdata. In particular, the selected channel data for the current well 340includes gamma-ray data 320(1), resistivity data 324(1), lithography328(1), and fluid density 332(1). The input data for the current well340 includes gamma-ray trend lines 322(1) (also referred to herein asshale lines) and a resistivity-trend line 326(1) (also referred toherein as a normal compaction trend). The calculated data for thecurrent well 340 includes pore pressure 330(1) and fracture gradient334(1). The casing-point data includes one or more casing points 336(1)(which are updated in real time).

With respect to the offset well 342, the real-time display 314 showsselected channel data, input data, calculated data, casing-point data,and event data. It should be appreciated that all such data for theoffset well 342 is generally historical drilling-performance data (asopposed to real-time data for the current well 340). In particular, theselected channel data for the offset well 342 includes gamma-ray data320(2), resistivity data 324(2), lithography 328(2), and fluid density332(2). The input data for the offset well 342 includes gamma-ray trendlines 322(2) (also referred to herein as shale lines) and aresistivity-trend line 326(2) (also referred to herein as a normalcompaction trend). The calculated data for the current well 340 includespore pressure 330(2) and fracture gradient 334(2). The casing-point dataincludes one or more casing points 336(2). The event data for the offsetwell 342 includes one or more drilling events 338.

With respect to the current well 340, acquisition of the input data willnow be described. As mentioned above, the selected channel data for thecurrent well 340 is displayed and refreshed in real-time as such data isreceived by a central computing system such as, for example, the centralcomputing system 108 of FIG. 1. As the selected channel data isreceived, the central computing system 108 gathers the input data, i.e.,the gamma-ray trend lines 322(1) and the resistivity-trend line 326(1).In a typical embodiment, the gamma-ray trend lines 322(1) are traced bydrilling personnel such as, for example, a drilling, geological orgeophysical engineer, who determines points of shale. Shale, as one ofordinary skill in the art will appreciate, generally emit more gammarays than other sedimentary rocks. The gamma-ray trend lines 322(1)generally connect points of shale and represent an average of thegamma-ray data 320(1) between those shale points (i.e. spanning thattrend line). For example, in various embodiments, a drilling engineermay be prompted at configurable points in time to trace the gamma-raytrend lines.

The resistivity-trend line 326(1) is typically acquired automaticallyfrom historical drilling-performance data for the offset well 342. Inthat way, the resistivity-trend line 326(2) (i.e., the normal compactiontrend for the offset well 342) serves as the resistivity-trend line326(1). The resistivity-trend line 326(2) is a normalization of theresistivity data 324 for the offset well 342.

The calculated data for the current well 340 is generated by a centralcomputing system such as, for example, the central computing system 108of FIG. 1, based on the selected channel data and the input data for thecurrent well 340. In a typical embodiment, the calculated data for thecurrent well 340 has defined relationships, established on the centralcomputing system 108 of FIG. 1, with the selected channel data and theinput data. Particularly, the gamma-ray data 320(1), the gamma-ray trendlines 322(1), the resistivity data 324(1), and the resistivity-trendline 326(1) are leveraged by a calculation engine such as, for example,the calculation engine 128, to compute the pore pressure 330(1) and thefracture gradient 334(1) in real time. In that way, published algorithmssuch as those developed by Eaton and Matthews and Kelly may be used inreal time to compute the pore pressure 330(1) and the fracture gradient334(1).

Moreover, the real-time display 314 also enables other types ofreal-time drilling-performance analyses. As one example of real-timedrilling-performance analysis, the real-time display 314 enablesdrilling personnel such as, for example, drilling engineers, to performreal-time geopressure analysis. Drilling engineers are able to comparethe pore pressure 330(1) and the fracture gradient 334(1) for thecurrent well 340 with the pore pressure 330(2) and the fracture gradient334(2) for the offset well. This real-time geopressure analysis allowsdrilling engineers to compare trends and anticipate changes based on theoffset well 342. The geopressure analysis can also be correlated withthe one or more drilling events 338, as described further below.

Further real-time drilling-performance analysis is enabled by the one ormore drilling events 338. Each of the one or more drilling events 338 istypically plotted at a depth at which a defined adverse drilling eventoccurred in the offset well 342. The one or more drilling events 338 caninclude, for example, stuck pipes, lost circulation, kicks, and thelike. As a result of the geographic proximity between the current well340 and the offset well 342, circumstances that led to the one or moredrilling events 338 are often likely to reoccur at similar depths in thecurrent well 340. Therefore, the real-time display 314 allows drillingpersonnel to anticipate and plan for the one or more drilling events338. In a typical embodiment, when the depth of the current well 340 iswithin a preconfigured distance of the depth at which one of the one ormore drilling events 338 occurred (e.g., 500 feet), an alert isgenerated and presented to responsible personnel. The alert can be, forexample, a beep or alarm. Responsive to the alert, the responsiblepersonnel may perform, for example, the real-time geopressure analysisdescribed above so that it can be determined if the pore pressure 330(1)is trending similarly to the pore pressure 330(2). Corrective actionsuch as an adjustment in the fluid density 332(1) may be taken.

As another example of real-time drilling-performance analysis, thereal-time display 314 further enables casing-point prediction. Asdescribed above, the real-time display 314 shows the one or more casingpoints 336(1) for the current well 340 and the one or more casing points336(2) for the offset well 342. Using data from the casing points336(2), drilling personnel are able to predict both size and placementfor future casing points for the current well 340.

A further example of real-time drilling-performance analysis enabled bythe real-time display 314 relates to density analysis. As describedabove, the real-time display 314 displays both the fluid density 332(1)for the current well 340 and the fluid density 332(2) for the offsetwell 342. By reviewing and comparing density trends, drilling personnelsuch as, for example, drilling engineers, are able to determine if thefluid density 332(1) for the current well 340 should be increased,decreased, or maintained.

In a typical embodiment, the real-time display 314 can be customizedbased on the desires of drilling engineers. For example, the selectedchannel data can include more, less, or different channel data thandescribed above. Likewise, the calculated data can have definedrelationships with other channel data and/or input data for purposes ofperforming different calculations in real time.

Finally, real-time drilling performance analyses such as those describedabove allow drilling personnel such as, for example, drilling,geological, or geophysical engineers, to reduce non-productive time(NPT). Alerts, recommendations, and real-time displays such as thosedescribed above allow drilling personnel to perform better analyses morequickly and more efficiently. The automation provided by a system suchas, for example, the real-time drilling-performance analysis system 100of FIG. 1, frees drilling personnel from manually gathering informationnecessary to analyze and make decisions regarding the drillingperformance of a well.

Although various embodiments of the method and apparatus of the presentinvention have been illustrated in the accompanying Drawings anddescribed in the foregoing Detailed Description, it will be understoodthat the invention is not limited to the embodiments disclosed, but iscapable of numerous rearrangements, modifications and substitutionswithout departing from the spirit of the invention as set forth herein.

What is claimed is:
 1. A method comprising, by a computer system:collecting channel data in real-time as the channel data is generated,the channel data comprising measured physical properties determined bysensors in use at a site of a first well; providing a real-time displayof performance data for the first well; retrieving input data comprisinghistorical performance data for a second well, wherein the historicalperformance data comprises an event for the second well; updating thereal-time display with the event for the second well; and generating analert responsive to a determination that a measured depth for the firstwell is within a preconfigured distance of a depth associated with theevent for the second well.
 2. The method of claim 1, wherein theperformance data comprises casing-point data for the first well and thesecond well.
 3. The method of claim 1, wherein the event for the secondwell comprises event data for an adverse drilling event that previouslyoccurred with respect to the second well.
 4. The method of claim 1,comprising: computing data for the first well based on the channel datacomprising measured physical properties determined by sensors in use atthe site of the first well and input data comprising the historicalperformance data for the second well; and updating the real-time displaywith the computed data.
 5. The method of claim 4, wherein the real-timedisplay comprises a comparative display of at least a portion of thehistorical performance data for the second well and at least a portionof the performance data for the first well relative to depth.
 6. Themethod of claim 4, wherein the computed data comprises pore pressure. 7.The method of claim 6, wherein: the input data comprises resistivitydata for the second well; the channel data comprises resistivity datafor the first well; and the computing comprises computing the porepressure using the resistivity data for the first well and theresistivity data for the second well.
 8. The method of claim 6, whereinthe computed data comprises a fracture gradient.
 9. The method of claim8, wherein the retrieving comprises retrieving at least a portion of theinput data from settings maintained by a calculation engine resident onthe computing system.
 10. The method of claim 9, wherein the at least aportion of the input data comprises at least one of a matrix stresscoefficient and a Poisson ratio.
 11. A system comprising a processor andmemory, wherein the processor and memory in combination are operable toimplement a method comprising: collecting channel data in real-time asthe channel data is generated, the channel data comprising measuredphysical properties determined by sensors in use at a site of a firstwell; providing a real-time display of performance data for the firstwell; retrieving input data comprising historical performance data for asecond well, wherein the historical performance data comprises an eventfor the second well; updating the real-time display with the event forthe second well; and generating an alert responsive to a determinationthat a measured depth for the first well is within a preconfigureddistance of a depth associated with the event for the second well. 12.The system of claim 11, wherein the performance data comprisescasing-point data for the first well and the second well.
 13. The systemof claim 11, wherein the event for the second well comprises event datafor an adverse drilling event that previously occurred with respect tothe second well.
 14. The system of claim 11, the method comprising:computing data for the first well based on the channel data comprisingmeasured physical properties determined by sensors in use at the site ofthe first well and input data comprising the historical performance datafor the second well; and updating the real-time display with thecomputed data.
 15. The system of claim 14, wherein the real-time displaycomprises a comparative display of at least a portion of the historicalperformance data for the second well and at least a portion of theperformance data for the first well relative to depth.
 16. The system ofclaim 14, wherein the computed data comprises pore pressure.
 17. Thesystem of claim 16, wherein: the input data comprises resistivity datafor the second well; the channel data comprises resistivity data for thefirst well; and the computing comprises computing the pore pressureusing the resistivity data for the first well and the resistivity datafor the second well.
 18. The system of claim 16, wherein the computeddata comprises a fracture gradient.
 19. The system of claim 18, whereinthe retrieving comprises retrieving at least a portion of the input datafrom settings maintained by a calculation engine resident on the system.20. A computer-program product comprising a non-transitorycomputer-usable medium having computer-readable program code embodiedtherein, the computer-readable program code adapted to be executed toimplement a method comprising: collecting channel data in real-time asthe channel data is generated, the channel data comprising measuredphysical properties determined by sensors in use at a site of a firstwell; providing a real-time display of performance data for the firstwell; retrieving input data comprising historical performance data for asecond well, wherein the historical performance data comprises an eventfor the second well; updating the real-time display with the event forthe second well; and generating an alert responsive to a determinationthat a measured depth for the first well is within a preconfigureddistance of a depth associated with the event for the second well.